Process for producing hydrocarbon material from a subterranean formation while employing solids control

ABSTRACT

There is provided a hydrocarbon production process including stimulating a hydrocarbon material-containing reservoir by hydraulic fracturing of the hydrocarbon material-containing reservoir with a treatment material including proppant. The treatment material is injected such that a frac pack is obtained. During production, hydrocarbon material is conducted from the reservoir to the surface via the frac pack. Flow control members are manipulated to enable injection of the treatment material and, subsequently, production of the hydrocarbon material from the reservoir.

CROSS-REFERENCE TO RELATED APPLICATION

This application is a continuation of U.S. patent application Ser. No.16/491,966 filed Mar. 8, 2018, which itself is a 371 international ofApplication No. PCT/CA2018/050277 filed Mar. 8, 2018, which itselfclaims the benefit of priority to U.S. Provisional Patent ApplicationNo. 62/469,019 filed Mar. 9, 2017, titled A PROCESS FOR PRODUCINGHYDROCARBON MATERIAL FROM A SUBTERRANEAN FORMATION WHILE EMPLOYINGSOLIDS CONTROL, the contents of which are hereby expressly incorporatedinto the present application by reference in their entirety.

FIELD

The present disclosure relates to production of hydrocarbon materialfrom a subterranean formation and controlling entrainment of solidswithin the produced hydrocarbon material.

BACKGROUND

Production of hydrocarbon reservoirs is complicated by the presence ofsolid particulate matter that is entrained within the produced fluid.Such solid particulate matter includes naturally-occurring solidsdebris, such as sand. It also includes solids, such as proppant, whichhave been intentionally injected into the reservoir, in conjunction withtreatment fluid, for improving the rate of hydrocarbon production fromthe reservoir. The entrained solids can complicate operations by causingerosion and interfering with fluid flow.

SUMMARY

There is provided a hydrocarbon production process, implemented via asystem including a wellbore string disposed within a wellbore extendinginto a subterranean formation, wherein the wellbore string includes aflow communication station including a material injection station and amaterial production station, wherein the material production station isdisposed downhole relative to the material injection station, whereinthe material injection station includes a material injection flowcontrol member for opening and closing a material injection flowcommunicator that is disposed in flow communication with thesubterranean formation via a wellbore space, and the material productionstation includes a material production flow control member for openingand closing a material production flow communicator that is disposed inflow communication with the subterranean formation via a wellbore space,wherein the material production flow communicator includes a filtermedium for preventing oversize particulate material from entering thewellbore string, comprising:

opening the material injection flow communicator by displacing thematerial injection flow control member, relative to the materialinjection flow communicator, from the closed position to the openposition with a shifting tool;

while: (i) the material injection flow communicator is disposed in theopen condition, and (ii) a sealed interface is disposed within thewellbore string, downhole relative to the material injection flowcommunicator, and uphole relative to the material production flowcommunicator, with effect that bypassing of the material injection flowcommunicator, by stimulation material injected from the surface, isprevented or substantially prevented, injecting stimulation material,including proppant, from the surface and into the subterraneanformation, via the wellbore string, the material injection flowcommunicator, and the wellbore space, such that hydraulic fracturing ofa hydrocarbon material-containing reservoir of the subterraneanformation is effected;

continuing to inject the stimulation material with effect that a screenout is obtained, with effect that the frac pack is obtained within thewellbore space, between the subterranean formation and the materialproduction flow communicator; and

after the frac pack has been obtained:

-   -   opening the material production flow communicator by displacing        the material production flow control member, relative to the        material production flow communicator, from the closed position        to the open position, with a shifting tool; and    -   after the opening of the material production flow communicator,        producing hydrocarbon material from the subterranean formation        via the frac pack, the material production station and the        wellbore string.

In another aspect, there is provided a hydrocarbon production process,implemented via a system including a wellbore string disposed within awellbore extending into a subterranean formation, wherein the wellborestring includes a material injection station and a material productionstation, wherein the material production station is disposed downholerelative to the material injection station, wherein the materialinjection station includes a material injection flow controller formodulating a flow communication condition of a material injection flowcommunicator that is disposed in flow communication with thesubterranean formation via a wellbore space, and the material productionstation includes a material production flow controller for modulating aflow communication condition of a material production flow communicatorthat is disposed in flow communication with the subterranean formationvia a wellbore space, wherein the material production flow communicatorincludes a filter medium for preventing oversize particulate materialfrom entering the wellbore string, comprising:

opening the material injection flow communicator by displacing thematerial injection flow controller relative to the material injectionflow communicator;

while the material injection flow communicator is disposed in the opencondition, injecting stimulation material, including proppant entrainedwithin a fluid, from the surface and into the subterranean formation,via the wellbore string, the material injection flow communicator, andthe wellbore space, such that hydraulic fracturing of a hydrocarbonmaterial-containing reservoir of the subterranean formation is effected;

suspending the injection of the stimulation material;

after the suspending of the injection of the stimulation material,partially opening the material production flow communicator bydisplacing the material production flow controller relative to thematerial production flow communicator, such that:

-   -   (i) an uphole-disposed portion of the material production flow        communicator is occluded by the material production flow        controller; and    -   (ii) flow communication is effected between the subterranean        formation and the wellbore string via a downhole-disposed        portion of the material production flow communicator, such that        reservoir material is conducted from the subterranean formation        and into the wellbore string via the downhole-disposed portion        of the material production flow communicator in response to a        pressure differential between the subterranean formation and the        wellbore string, and such that solid particulate material,        entrained within the conducted reservoir material, separates        from the conducted reservoir material and accumulates within the        wellbore space, that is disposed between the subterranean        formation and the material production flow communicator, and at        least contributes to formation of a solid particulate        material-containing filtering medium;    -   wherein the downhole-disposed portion of the material production        flow communicator is disposed downhole relative to the        uphole-disposed portion of the material production flow        communicator;

and

-   -   after the formation of a solid particulate material-containing        filtering medium, increasing the percentage opening of the        material production flow communicator by displacing the material        production flow controller relative to the material production        flow communicator such that a production mode material        production flow communicator is established, with effect that        reservoir material is conducted from the subterranean formation        and into the wellbore string via the solid particulate        material-containing filtering medium and the production mode        material production flow communicator.

BRIEF DESCRIPTION OF DRAWINGS

The preferred embodiments will now be described with the followingaccompanying drawings, in which:

FIG. 1 is a schematic illustration of a system of the presentdisclosure;

FIG. 1A is a schematic illustration of an embodiment of an apparatus ofthe material injection station of the system illustrated in FIG. 1,showing the flow control member disposed in the closed position;

FIG. 1B is a schematic illustration of the apparatus of the materialinjection station illustrated in FIG. 1A, showing the flow controlmember disposed in the open position;

FIG. 2 is a sectional view of an embodiment of an apparatus of thematerial production station of the system illustrated in FIG. 1, showingthe flow control member disposed in the closed position;

FIG. 2A is a detailed view of Detail A in FIG. 2;

FIG. 2B is a detailed view of Detail B in FIG. 2

FIG. 2C is a detailed view of Detail C in FIG. 2;

FIG. 3 is a sectional view of the apparatus illustrated in FIG. 2,showing the flow control member disposed in the intermediate position;

FIG. 3A is a detailed view of Detail A in FIG. 3;

FIG. 3B is a detailed view of Detail B in FIG. 3;

FIG. 3C is a detailed view of Detail C in FIG. 3;

FIG. 4 is a sectional view of the apparatus illustrated in FIG. 2,showing the flow control member disposed in the open position;

FIG. 4A is a detailed view of Detail A in FIG. 4;

FIG. 4B is a detailed view of Detail B in FIG. 4;

FIG. 4C is a detailed view of Detail C in FIG. 4;

FIG. 5 is a schematic illustration of a partially completed embodimentof the screened port of the apparatus illustrated in FIG. 2, showingscreen having been wrapped around a portion of a perforated base pipe;

FIG. 6 is a schematic illustration of an exemplary flow communicationstation of a system of the present disclosure;

FIG. 7 is a schematic illustration of the system illustrated in FIG. 6,showing injection of stimulation material into subterranean formationvia the material injection station for formation of a frac pack;

FIG. 8 is a schematic illustration of an exemplary flow communicationstation of the system illustrated in FIG. 6, after a frac pack has beenobtained, and while a clean out is on-going;

FIG. 9 is a schematic illustration of the system illustrated in FIG. 6during production;

FIG. 10 is a schematic illustration of another exemplary flowcommunication station of a system of the present disclosure;

FIG. 11 is a schematic illustration of the system illustrated in FIG.10, showing injection of stimulation material into subterraneanformation, via the material injection station, for effecting hydraulicfracturing of the subterranean formation;

FIG. 12 is a schematic illustration of the system in FIG. 10, after theinjection of stimulation material has been suspended and the materialproduction flow communicator has been partially opened; and

FIG. 13 is a schematic illustration of the system in FIG. 10, after thethe material production flow communicator has been fully opened.

DETAILED DESCRIPTION

Referring to FIG. 1, there is provided a system 2 for producinghydrocarbon material from a subterranean formation 100 including aplurality of flow communication stations (in the illustrated embodiment,five, 200A-E, are illustrated) disposed within a wellbore 102.Successive flow communication stations 200A-E are spaced from each otherwithin the wellbore 102, along a longitudinal axis of the wellbore 102,such that each one of the flow communication stations 200A-E,independently, is positioned adjacent a zone of the subterraneanformation for effecting flow communication between the wellbore 102 andthe zone. In this respect, each one of the flow communication stations200A-E, independently, is configured for effecting flow communicationbetween the surface and a respective zone within the subterraneanformation 100.

The wellbore 102 can be straight, curved, or branched. The wellbore 102can have various wellbore sections. A wellbore section is an axiallength of a wellbore 102. A wellbore section can be characterized as“vertical” or “horizontal” even though the actual axial orientation canvary from true vertical or true horizontal, and even though the axialpath can tend to “corkscrew” or otherwise vary. The term “horizontal”,when used to describe a wellbore section, refers to a horizontal orhighly deviated wellbore section as understood in the art, such as, forexample, a wellbore section having a longitudinal axis that is between70 and 110 degrees from vertical.

In some embodiments, for example, for each one of the flow communicationstations 200A-E, the flow communication, between the flow communicationstation and the respective zone of the subterranean formation, iseffected by integrating the flow communication station 200, insuccession, into a production string 202 that is disposed within thewellbore 102. In some of these embodiments, for example, the dispositionof the production string 202 within the wellbore 102 is such that awellbore space 104, such as an annular space, is established within thewellbore 102, between the production string 202 and the subterraneanformation 100.

The wellbore space includes a plurality of wellbore space sections104A-E. Each one of the wellbore space sections 104A-E, independently,is respective to a one of the flow communication stations 200A-E, suchthat, for each one of the flow communication stations 200A-E, flowcommunication, between the flow communication station and thesubterranean formation, is effected via a respective one of the wellborespace sections 104A-E.

Each one of the flow communication stations 200A-E, independently,includes a material injection station 204 and a material productionstation 206.

For each one of the flow communication stations 200A-E, independently,the material injection station 204 includes an apparatus 2042. Referringto FIGS. 1A and 1B, the apparatus 2042 includes a housing 2044. Thehousing 2044 includes a passage 2046. A material injection flowcommunicator 2048 extends through the housing 2044. In some embodiments,for example, the material injection flow communicator 2048 includes oneor more ports. The material injection flow communicator 2048 isconfigured for effecting flow communication between the housing passage2046 and the subterranean formation.

The apparatus 2042 further includes a material injection flow controller2050 configured for controlling flow communication between the housingpassage 2046 and the material injection flow communicator 2048. In someembodiments, for example, the material injection flow controller 250 isa flow control member 250. In some embodiments, for example, thematerial injection flow controller 250 is in the form of a sleeve thatis slidable, relative to the flow communicator 2048, within the housingpassage 2046. In some embodiments, for example, the flow control member2050 is configured for opening and closing the material injection flowcommunicator 2048.

In some embodiments, for example, while the flow control member 2050 isdisposed in the closed position (see FIG. 1A), the material injectionflow communicator 2048 is disposed in a closed condition. In someembodiments, for example, in the closed condition, the flow communicator2048 is occluded by the flow control member 2050. In some embodiments,for example, while the flow communicator 2048 is disposed in the closedcondition, there is an absence, or substantial absence of fluidcommunication between the passage 2046 and the subterranean formation100 via the material production flow communicator 2048. In other words,fluid communication between the passage 2046 and the subterraneanformation 100 via the flow communicator 2048 is prevented orsubstantially prevented. In some embodiments, for example, while theflow control member 2050 is disposed in the closed position, a sealedinterface is established, preventing, or substantially preventing, flowcommunication, via the material injection flow communicator 2048,between the surface 4 and the subterranean formation 100. In someembodiments, for example, the closed position of the material injectionflow control member 2050 is established by abutting engagement of theflow control member 2050 with the hard stop 2060 that is disposed upholeof the material injection flow communicator 2048.

In some embodiments, for example, while the flow control member 2050 isdisposed in the open position (see FIG. 1B), flow communication, betweenthe surface and the respective zone of the subterranean formation 100,is effected via the material injection flow communicator 2048. In someembodiments, for example, while the flow control member 250 is disposedin the open position, the flow communicator 2048 is disposed in an opencondition. In some embodiments, for example, while the flow communicatoris disposed in the open condition, there is an absence of occlusion ofany portion, or substantially any portion, of the flow communicator 2048by the flow control member 250. In some embodiments, for example, thedisposition of the flow control member 250 in the open position is suchthat the entirety, or substantially the entirety, of the flowcommunicator 2048 is non-occluded by the flow control member 250. Insome embodiments, for example, the open position of the materialinjection flow control member 2050 is established by abutting engagementof the flow control member 2050 with the hard stop 2062 that is disposeddownhole of the material injection flow communicator 2048.

In some embodiments, for example, while the flow control member 250 isdisposed in the closed position, the flow control member 250 isreleasably retained relative to the housing 2044. Similarly, in someembodiments, for example, while the flow control member 250 is disposedin the open position, the flow control member 250 is releasably retainedrelative to the housing 2044. The releasable retention of the flowcontrol member 250, relative to the housing 2044, can be effected by acollet retainer 2070, similar to the manner by which the flow controlmember 14, of the material production station 206, is releasablyretained by a collet retainer 22, as described below.

While the material injection flow communicator 2048 is disposed in theopen condition, treatment material is injectable from the surface andinto the subterranean formation via the flow communicator 2048 forstimulating production of a hydrocarbon material-containing reservoirwithin the subterranean formation.

In some embodiments, for example, the treatment material includes aliquid, such as a liquid including water. In some embodiments, forexample, the liquid includes water and chemical additives. In otherembodiments, for example, the stimulation material is a slurry includingwater and solid particulate matter, such as proppant. In someembodiments, for example the treatment material includes chemicaladditives. Exemplary chemical additives include acids, sodium chloride,polyacrylamide, ethylene glycol, borate salts, sodium and potassiumcarbonates, glutaraldehyde, guar gum and other water soluble gels,citric acid, and isopropanol. In some embodiments, for example, thetreatment material is injected into the subterranean formation foreffecting hydraulic fracturing of the reservoir.

In some embodiments, for example, while the apparatus 10 is beingdeployed downhole, the flow control member 250 is maintained in theclosed position, by one or more frangible interlocking members 2501(such as, for example, shear pins), such that the material injectionflow communicator 2048 remains disposed in the closed condition whilethe deployment is occurring. The one or more frangible interlockingmembers are provided to releasably secure the flow control member 250 tothe housing 2044 so that the passage 2046 is maintained fluidicallyisolated from the subterranean formation 100 until it is desired toeffect hydrocarbon production from the subterranean formation 100.

For each one of the flow communication stations 200A-E, independently,the material production station 206 includes an apparatus 10. Referringto FIGS. 2 to 5, the apparatus 10 includes a housing 12. The housing 12includes a passage 16. A material production flow communicator 15extends through the housing 12. In some embodiments, for example, thematerial production flow communicator 15 includes one or more ports. Thematerial injection flow communicator 15 is configured for effecting flowcommunication between the housing passage 16 and the subterraneanformation, such as for effecting the receiving of hydrocarbon material,from the subterranean formation, by the production string 202. Thematerial production flow communicator 15 includes a filter medium 15Aconfigured for preventing, or substantially preventing, oversize solidparticulate matter from being conducted from the subterranean formation100 and into the production string 202. In some embodiments, forexample, the filter medium is in the form of a screen, such as a wirescreen. In some embodiments, for example, the filter medium 15A isdefined by a sand screen that is wrapped around a perforated section(defined by ports 15C) of a base pipe 15B, the perforated sectiondefining a plurality of apertures. In some embodiments, for example, thefilter medium is in the form of a porous material that is integratedwithin an aperture of a base pipe. In some embodiments, for example, thefilter medium is configured for preventing, or substantially preventing,passage of +100 mesh proppant from the subterranean formation 100, viathe material production flow communicator 15, and into the productionstring 202.

The apparatus 10 further includes a material production flow controller14 configured for controlling flow communication between the housingpassage 16 and the material production flow communicator 15. In someembodiments, for example, the material production flow controller 14 isa flow control member 14. In some embodiments, for example, the flowcontrol member 14 is in the form of a sleeve that is slidable, relativeto the flow communicator 15, within the housing passage 16. In someembodiments, for example, the flow control member 14 is configured foropening and closing the material injection flow communicator 15.

For each one of the flow communication stations 200A-E, the integrationof the flow communication station into the production string 202 is witheffect that the material production station 206 is disposed downholerelative to the material injection station 204.

Referring to FIGS. 2, 2A, 2B, and 2C, while the flow control member 14is disposed in the closed position, the material production flowcommunicator is disposed in the closed condition. In some embodiments,for example, in the closed condition, the entirety, or the substantialentirety, of the material production flow communicator 15 is occluded bythe flow control member 14. In some embodiments, for example, while theflow communicator 15 is disposed in a closed condition, there is anabsence, or substantial absence of fluid communication between thepassage 16 and the subterranean formation 100 via the materialproduction flow communicator 15. In other words, fluid communicationbetween the passage 16 and the subterranean formation 100 via thematerial production flow communicator 15 is prevented or substantiallyprevented. In some embodiments, for example, while the flow controlmember 14 is disposed in the closed position, a sealed interface isestablished, preventing, or substantially preventing, flowcommunication, via the material production flow communicator 15, betweenthe surface 4 and the subterranean formation 100.

Referring to FIGS. 4, 4A, 4B, and 4C, while the flow control member 14is disposed in the open position, flow communication, between thesurface and the respective zone of the subterranean formation 100, iseffected via the material production flow communicator 15. In someembodiments, for example, while the flow control member is disposed inthe open position, the material production flow communicator 15 isdisposed in an open condition. In some embodiments, for example, whilethe material production flow communicator 15 is disposed in the opencondition, there is an absence of occlusion of any portion, orsubstantially any portion, of the material production flow communicator15 by the flow control member 14; In some embodiments, for example, thedisposition of the flow control member 14 in the open position is suchthat the entirety, or substantially the entirety, of the materialproduction flow communicator 15 is non-occluded by the flow controlmember 14.

In some embodiments, for example, the flow control member 14 isdisplaceable from the closed position to the open position for effectingflow communication between the subterranean formation 100 and thepassage 16 such that reservoir fluids are producible via the wellbore102.

In some embodiments, for example, the flow control member 14 isdisplaceable from the open position to the closed position while fluidsare being produced from the subterranean formation 100 through thematerial production flow communicator 15, and in response to sensing ofa sufficiently high rate of water production from the subterraneanformation 100 through the material production flow communicator 15. Insuch case, moving the flow control member 14 blocks further productionthrough the material production flow communicator 15.

In some embodiments, for example, the flow control member 14 isdisplaceable along an axis that is parallel to the central longitudinalaxis of the passage 16.

In some embodiments, for example, the housing 12 includes sealingsurfaces 11A, 11B configured for sealing engagement with the flowcontrol member 14 for effecting the sealed interface coincident with theflow communicator 15 being disposed in the closed condition. In thisrespect, in some embodiments, for example, the flow control member 14includes sealing members 11AA, 11BB. The material production flowcommunicator 15 is disposed between the sealing surfaces 11A, 11B. Insome embodiments, for example, when the flow control member 14 isdisposed in a position corresponding to the closed position of the flowcommunicator 15, each one of the sealing members 11AA, 11BB, is,independently, disposed in sealing engagement with both of the housing12 and the flow control member 14.

In some embodiments, for example, each one of the sealing members 11AA,11BB, independently, includes an o-ring. In some embodiments, forexample, the o-ring is housed within a recess formed within the flowcontrol member 14. In some embodiments, for example, each one of thesealing members 11AA, 11BB, independently, includes a molded sealingmember (i.e. a sealing member that is fitted within, and/or bonded to, agroove formed within the sub that receives the sealing member).

In some embodiments, for example, the flow control member 14 co-operateswith the sealing surfaces 11A, 11B to effect opening and closing of thematerial production flow communicator 15. While the material productionflow communicator 15 is disposed in the closed position, the flowcontrol member 14 is sealingly engaged to both of the sealing surfaces11A, 11B. While the material production flow communicator 15 is disposedin the open condition, the flow control member 14 is spaced apart orretracted from at least one of the sealing surfaces (referring to FIG.4, in the illustrated embodiment, this would be the sealing surface11B), thereby providing a passage for reservoir material to be conductedto the passage 16 via the material production flow communicator 15.

In some embodiments, while disposed in the closed position, the flowcontrol member 14 is releasable retained relative to the housing 12. Inthis respect, in some embodiments, for example, a retaining collet 22extends from the housing 12, and is configured to engage the flowcontrol member 14 for resisting a displacement of the flow controlmember. In some embodiments, for example, the retaining collet 22includes at least one resilient flow control member-engaging colletfinger 22A, and each one of the at least one flow controlmember-engaging collet finger includes a tab 22B that engages the flowcontrol member. The flow control member 14 and the retaining collet 22are co-operatively configured such that engagement of the flow controlmember 14 by the flow control member-engaging collet 22 is effectedwhile the material production flow communicator 15 is disposed in theclosed condition.

Referring to FIGS. 2, 2A, 2B, and 2C, while the flow control member 14is disposed in the closed position (i.e. the material production flowcommunicator 15 is disposed in the closed condition) the retainingcollet 22 is engaging the flow control member 14 such that interferenceor resistance is being effected to displacement of the flow controlmember 14, such that the flow control member 14 is releasably retainedrelative to the housing 12. The flow control member 14 includes a closedcondition-defining recess 24. The at least one flow controlmember-engaging collet finger 22A and the recess 24 are co-operativelyconfigured such that, while the flow control member-engaging colletfinger tab 22B is disposed within the closed condition-defining recess24, the flow control member 14 is disposed in the closed position. Inorder to effect a displacement of the flow control member 14, while theflow control member-engaging collet finger tab 22B is disposed withinthe closed condition-defining recess 24, a first displacement force isapplied to the flow control member 14 to effect displacement of the tab22B from (or out of) the recess 24. Such displacement is enabled due tothe resiliency of the collet finger 22A. Once the flow controlmember-engaging collet finger tab 22B has become displaced out of therecess 24, continued application of force to the flow control member 14(such as, in the embodiments illustrated in FIGS. 2, 2A, 2B, and 2C, ina downhole direction) effects displacement of the flow control member14, relative to the material production flow communicator 15.

Similarly, in some embodiments, for example, while disposed in the openposition, the flow control member 14 is releasably retained relative tothe housing 12, such as, for example, by the retaining collet 22. Inthis respect, and referring to FIGS. 4, 4A, 4B, and 4C, while the flowcontrol member 14 is disposed in the open position (i.e. the materialproduction flow communicator 15 is disposed in the open condition), theretaining collet 22 is engaging the flow control member 14 such thatinterference or resistance is being effected to displacement of the flowcontrol member 14, such that the flow control member 14 is releasablyretained relative to the housing 12. The flow control member 14 includesan open condition-defining recess 26. The at least one flow controlmember-engaging collet finger 22A and the recess 26 are co-operativelyconfigured such that, while the flow control member-engaging colletfinger tab 22B is disposed within the open condition-defining recess 26,the flow communicator 15 is disposed in the open condition. In order toeffect a displacement of the flow control member 14, while the flowcontrol member-engaging collet finger tab 22B is disposed within theopen condition-defining recess 26, a second displacement force isapplied to the flow control member 14 to effect displacement of the tabfrom (or out of) the recess 26. Such displacement is enabled due to theresiliency of the collet finger 22A. Once the flow controlmember-engaging collet finger tab 22B has become displaced out of therecess 26, continued application of the second displacement force to theflow control member 14 (such as, in the embodiment illustrated in FIG.2, in a downhole direction) effects displacement of the flow controlmember 14, relative to the material production flow communicator 15.

Referring to FIG. 2, in some embodiments, for example, while theapparatus 10 is being deployed downhole, the flow control member 14 ismaintained in the closed position, by one or more frangible interlockingmembers 30 (such as, for example, shear pins), such that the materialproduction flow communicator 15 remains disposed in the closed conditionwhile the deployment is occurring. The one or more frangibleinterlocking members 30 are provided to releasably retain the flowcontrol member 14 to the housing 12 so that the passage 16 is maintainedfluidically isolated from the subterranean formation 100 until it isdesired to effect hydrocarbon production from the subterranean formation100. In some embodiments, for example, the one or more frangibleinterlocking members 30 extends through apertures 14B provided in acentralizer portion 14A of the flow control member 14.

While the flow control member 14 is releasably retained to the housingby the one or more frangible interlocking members 30, the flow controlmember 14 is disposed in a retained position. To effect the fracturingof the frangible interlocking members 30 such that the flow controlmember 14 is displaceable relative to the material production flowcommunicator 15, sufficient force must be applied to the flow controlmember 14 such that the one or more frangible interlocking members 30become fractured, resulting in the flow control member 14 becomingdisplaceable relative to the material production flow communicator 15.

In some embodiments, for example, while the flow control member 14 isretained relative to the housing 12 by the one or more frangibleinterlocking members 30, the flow control member 14 is positioneddownhole relative to the space occupied by the flow control member 14while disposed in the open position. In such embodiments, for example,the one or more frangible interlocking members 30 are configured forfracturing (such that the flow control member 14 is displaceablerelative to the material production flow communicator 15) by applicationof a sufficient downhole force. Upon the fracturing of the one or morefrangible interlocking members 30, continued application of the downholeforce effects displacement of the flow control member 14 in a downholedirection. If the downhole force were permitted to continue to effectthe displacement of the flow control member 14 in a downhole direction(such as, for example to effect opening of the material production flowcommunicator 15), the flow control member 14 would continue toaccelerate, and attain a sufficiently high speed, such that, upon rapiddeceleration of the flow control member 14 caused by an obstruction toits downhole displacement (such as by a hard stop), associatedcomponents become vulnerable to damage. In this respect, thedisplacement of the flow control member 14, relative to the flowcommunicator 15, in a downhole direction, that is effected after thefracturing of the one or more frangible interlocking members 30, islimited by a hard stop 32 that extends from the housing 12 and into thepassage 16. The flow control member 14 and the hard stop 32 areco-operatively configured such that, while the flow control member 14 isdisposed in abutting engagement with the hard stop 32 (i.e. the flowcontrol member 14 is disposed in the downhole displacement-limitedposition), displacement of the flow control member 14 relative to theflow communicator 15, in the downhole direction, is prevented orsubstantially prevented by the hard stop 32. The flow control member,14, while disposed in the releasably retained position by the one ormore frangible interlocking members 30, and the hard stop 32 areco-operatively disposed such that the distance by which the flow controlmember 14 is displaced by the applied force, after its release fromretention relative to the housing 12 by the one or more frangibleinterlocking members 30, is sufficiently short such that the speedattained by the flow control member 14, during the displacement of theflow control member 14 relative to the flow communicator 15, issufficiently slow such that there is an absence of undesirablemechanical damage to associated components upon impact (i.e the abuttingengagement) of the hard stop 32 by the flow control member 14 (see FIGS.3, 3A, 3B, and 3C). In this respect, In some embodiments, for example,the distance by which the flow control member 14 is displaced, relativeto the flow communicator 15, between the retained position and thedownhole-displacement limited position, as measured along the centrallongitudinal axis of the passage 16, is less than six (6) inches, suchas less than three (3) inches, such as less than two (2) inches.

Relatedly, in those embodiments where the material production flowcommunicator 15 has a dimension, measured along an axis that is parallelto the central longitudinal axis of the passage 16, that is greater thanthe distance by which the flow control member 14 is displaced, relativeto the flow communicator 15, from the secured position and the downholedisplacement-limited position, as measured along the centrallongitudinal axis of the passage, in order to effect opening of the flowcommunicator 15 such that the flow communicator becomes disposed in thenon-occluded condition (i.e. there is an absence, or substantialabsence, of occlusion of any portion of the flow communicator 15 by theflow control member 14), the displacement of the flow control member 14,relative to the flow communicator 15, from the retained position to theopen position, is a displacement in the uphole direction. Otherwise, ifsuch displacement of the flow control member 14, relative to the flowcommunicator 15, for effecting opening of the flow communicator 15 suchthat the flow communicator 15 becomes disposed in the non-occludedcondition, were a displacement in the downhole direction, the hard stop32 would need to, correspondingly, be positioned further downhole so asto permit sufficient downhole displacement of the flow control member 14to effect the opening of the material production flow communicator 15.In such case, as a consequence, the speed attainable by the flow controlmember 14, while the downhole force continues to be applied (after thefracturing of the one or more frangible interlocking members 30) foreffecting such displacement, is sufficiently high such that associatedcomponents are vulnerable to damage upon the flow control member 14impacting (i.e. becoming disposed in abutting engagement with) the hardstop 32. Similar concerns about component damage are not present whiledisplacing the flow control member 14, relative to the flow communicator15, in an uphole direction, after having initially fractured the one ormore frangible interlocking members 30 with an applied force in thedownhole direction. This is because it is easier to maintain a lowerapplied force (such as, for example, a pulling up force applied to theworkstring to which the shifting tool is coupled) to effect such upholedisplacement, relative to the material production flow communicator 15,in these circumstances, relative to the above-described circumstanceswhere the displacement of the flow control member 14, to effect openingof the material production flow communicator 15, is effected by a forcethat continues to be applied after having effected the fracturing of theone or more frangible interlocking members 30.

In some embodiments, for example, a dimension of the material productionflow communicator 15, measured along an axis that is parallel, orsubstantially parallel, to the central longitudinal axis of the passage16, is at least one (1) foot, such as, for example, at least three (3)feet, such as, for example, at least five (5) feet, or such as, forexample, at least eight (8) feet. In some embodiments, for example, adimension of the material production flow communicator 15, measuredalong an axis that is parallel to the central longitudinal axis of thepassage 16, is ten (10) feet. Relatedly, the minimum distance, by whichthe flow control member 14 is displaced (in the uphole direction),relative to the flow communicator 15, along an axis that is parallel, orsubstantially parallel, to the central longitudinal axis of the passage16, from the retained position, wherein the displacement is with effectthat the flow communicator 15 becomes disposed in the non-occludedcondition, is at least one (1) foot, such as, for example, at leastthree (3) feet, such as, for example, at least five (5) feet, or suchas, for example, at least eight (8) feet, and, in some embodiments, forexample, is ten (10) feet. Also relatedly, the minimum distance, bywhich the flow control member 14 is displaced (in the uphole direction),relative to the flow communicator 15, along an axis that is parallel, orsubstantially parallel, to the central longitudinal axis of the passage16, from the retained position, wherein the displacement is with effectthat the entirety, or the substantial entirety, of the flow communicator15 is non-occluded by the flow control member 14, is at least one (1)foot, such as, for example, at least three (3) feet, such as, forexample, at least five (5) feet, or such as, for example, at least eight(8) feet, and, in some embodiments, for example, is ten (10) feet. Alsorelatedly, the distance, by which the flow control member 14 isdisplaced (in the uphole direction), relative to the flow communicator15, along an axis that is parallel, or substantially parallel, to thecentral longitudinal axis of the passage 16, from the closed position,wherein the displacement is with effect that the flow communicator 15becomes disposed in the non-occluded condition, is at least one (1)foot, such as, for example, at least three (3) feet, such as, forexample, at least five (5) feet, or such as, for example, at least eight(8) feet, and, in some embodiments, for example, is ten (10) feet. Alsorelatedly, the distance, by which the flow control member 14 isdisplaced (in the uphole direction), relative to the flow communicator15, along an axis that is parallel, or substantially parallel, to thecentral longitudinal axis of the passage 16, from the closed position,wherein the displacement is with effect that the entirety, or thesubstantial entirety, of the flow communicator 15 is non-occluded by theflow control member 14, is at least one (1) foot, such as, for example,at least three (3) feet, such as, for example, at least five (5) feet,or such as, for example, at least eight (8) feet, and, in someembodiments, for example, is ten (10) feet. Also relatedly, thedistance, by which the flow control member 14 is displaced (in theuphole direction), relative to the flow communicator 15, along an axisthat is parallel, or substantially parallel, to the central longitudinalaxis of the passage 16, from the position at which the flow controlmember 14 is disposed while in abutting engagement with the hard stop32, wherein the displacement is with effect that the flow communicator15 becomes disposed in the non-occluded condition, is at least 14inches, such as, for example, at least 38 inches, such as, for example,at least 62 inches, or such as, for example, at least 98 inches, and, insome embodiments, for example, is 122 inches. Also relatedly, thedistance, by which the flow control member 14 is displaced (in theuphole direction), relative to the flow communicator 15, along an axisthat is parallel, or substantially parallel, to the central longitudinalaxis of the passage 16, from the position at which the flow controlmember 14 is disposed while in abutting engagement with the hard stop32, wherein the displacement is with effect that the entirety, or thesubstantial entirety, of the flow communicator 15 is non-occluded by theflow control member 14, is at least 14 inches, such as, for example, atleast three (3) feet, such as, for example, at least 62 inches, or suchas, for example, at least 98 inches, and, in some embodiments, forexample, is 122 inches.

Referring to FIGS. 4, 4A, 4B, and 4C, in some embodiments, for example,the apparatus 10 includes a hard stop 34 for limiting displacement ofthe flow control member 14, in an uphole direction, relative to thematerial production flow communicator 15. In this respect, when disposedin abutting engagement with the hard stop 34, the flow control member 14is disposed in the open position. In this respect, the hard stop 34determines the open position of the flow control member 14.

In some embodiments, for example, all of the displacement forces areimparted by a shifting tool, and the shifting tool is integrated withina bottom hole assembly 208 that includes other functionalities. Thebottomhole assembly may be deployed within the wellbore on a workstring.Suitable workstrings include tubing string, wireline, cable, or othersuitable suspension or carriage systems. Suitable tubing strings includejointed pipe, concentric tubing, or coiled tubing. The workstringincludes a passage, extending from the surface, and disposed in, ordisposable to assume, fluid communication with the fluid conductingstructure of the tool. The workstring is coupled to the bottomholeassembly such that forces applied to the workstring are translated tothe bottomhole assembly to actuate movement of the flow control member14. All of the displacement forces are impartable in such embodiments bya shifting tool that is actuable by a workstring because, for amongstother reasons, each one of the first, second, and third positions aredetermined by a respective hard stop, and which, therefore, facilitatesthe positioning of the flow control member 14 such that positioning offlow control member is not entirely dependent on the manipulation of theshifting tool.

The flow communication stations 200A-E and the wellbore space sections104A-E are co-operatively configured such that, for each one of the flowcommunication stations 200A-E, independently:

(i) the flow communication station is disposed in flow communicationwith a respective zone of the subterranean formation 100 via therespective wellbore space section, and

-   -   (ii) flow communication between the respective wellbore space        section and the other ones of the wellbore space sections 104A-E        is sealed or substantially sealed such that:    -   (a) stimulation material, that is being injected from the        material injection station 204 of a flow communication station        and into the wellbore space section, is prevented, or        substantially prevented, from bypassing the respective zone of        the subterranean formation 100; and    -   (b) hydrocarbon material, that is being received within the        respective wellbore space section from the respective zone of        the subterranean formation 100, is prevented, or substantially        prevented, from bypassing the material production station 206.

In some embodiments, for example, the wellbore is a cased-holecompletion.

In some embodiments, for example, the wellbore 102 includes a cased-holecompletion. A cased-hole completion involves running casing down intothe wellbore 102 through the production zone. The casing 106 at leastcontributes to the stabilization of the subterranean formation 100 afterthe wellbore 102 has been completed, by at least contributing to theprevention of the collapse of the subterranean formation 100 that isdefining the wellbore 102. In some embodiments, for example, the casing106 includes one or more successively deployed concentric casingstrings, each one of which is positioned within the wellbore 102, havingone end extending from the well head 50. In this respect, the casingstrings are typically run back up to the surface. In some embodiments,for example, each casing string includes a plurality of jointed segmentsof pipe. The jointed segments of pipe typically have threadedconnections.

The annular region between the deployed casing 106 and the subterraneanformation 100 may be filled with zonal isolation material for effectingzonal isolation. The zonal isolation material is disposed between thecasing 106 and the subterranean formation 100 for the purpose ofeffecting isolation, or substantial isolation, of one or more zones ofthe subterranean formation 100 from fluids disposed in another zone ofthe subterranean formation 100. Such fluids include formation fluidbeing produced from another zone of the subterranean formation 100 (insome embodiments, for example, such formation fluid being flowed througha production string 202 disposed within and extending through the casing106 to the surface), or injected stimulation material. In this respect,in some embodiments, for example, the zonal isolation material isprovided for effecting sealing, or substantial sealing, of flowcommunication between one or more zones of the subterranean formation100 and one or more others zones of the subterranean formation 100 viaspace between the casing 106 and the subterranean formation 100. Byeffecting the sealing, or substantial sealing, of such flowcommunication, isolation, or substantial isolation, of one or more zonesof the subterranean formation 100, from another subterranean zone (suchas a producing formation) via the is achieved. Such isolation orsubstantial isolation is desirable, for example, for mitigatingcontamination of a water table within the subterranean formation 100 bythe formation fluids (e.g. oil, gas, salt water, or combinationsthereof) being produced, or the above-described injected fluids.

In some embodiments, for example, the zonal isolation material isdisposed as a sheath within an annular region between the casing 106 andthe subterranean formation 100. In some embodiments, for example, thezonal isolation material is bonded to both of the casing 106 and thesubterranean formation 100. In some embodiments, for example, the zonalisolation material also provides one or more of the following functions:(a) strengthens and reinforces the structural integrity of the wellbore,(b) prevents, or substantially prevents, produced formation fluids ofone zone from being diluted by water from other zones. (c) mitigatescorrosion of the casing 106, and (d) at least contributes to the supportof the casing 106. The zonal isolation material is introduced to anannular region between the casing 106 and the subterranean formation 100after the subject casing 106 has been run into the wellbore 102. In someembodiments, for example, the zonal isolation material includes cement.

In those embodiments where the wellbore is a cased-hole completion andthe production string 202 is spaced apart from the casing 106 such thatthe wellbore space is established, the casing 106 is perforated foreffecting flow communication between the flow communication stations200A-E and the subterranean formation 100. In this respect, a pluralityof perforations 110 extend from the wellbore space, through the casing106, and into the subterranean formation 100, and flow communicationbetween the flow communication stations 200A-E and the subterraneanformation 100 is effected via the wellbore space 104 and theperforations 100.

In this respect, the flow communication stations 200A-E, the wellborespace sections 104A-E, and the perforations are co-operativelyconfigured such that, for each one of the flow communication stations200A-E, independently:

(i) the flow communication station is disposed in flow communicationwith the respective zone of the subterranean formation 100 via therespective wellbore space section and a respective one or moreperforations 100, and

(ii) flow communication between the respective wellbore space sectionand the other ones of the wellbore space sections 104A-E is sealed orsubstantially sealed such that:

-   -   (a) stimulation material, that is being injected from the        material injection station 204 of a flow communication station        and into the wellbore space section, is prevented, or        substantially prevented, from bypassing the respective zone of        the subterranean formation 100; and    -   (b) hydrocarbon material, that is being received within the        respective wellbore space section from the respective zone of        the subterranean formation 100, is prevented, or substantially        prevented, from bypassing the material production station 206.

In some embodiments, for example, the sealing, or substantial sealing,of the flow communication is effected by disposing sealing members, suchas packers 108A-F, between adjacent ones of the wellbore space sections104A-E.

In some embodiments, for example, for each one of the flow communicationstations 200A-E, independently, the material production station 206 isdisposed in alignment, or substantial alignment, with the respective oneor more perforations 110.

In one aspect, a hydrocarbon material production process is implementedvia the system 100.

Referring to FIGS. 6 to 9, the process includes, for each one of theflow communication stations 200A-E, in succession in the upholedirection from the furthest downhole-disposed flow communicationstation, forming a frac pack between the one or more perforations andthe material production flow communicator 15. The frac pack, amongstother things, mitigates production of fine particulate matter. Theforming of a frac pack includes:

opening the material injection flow communicator 2048 by displacing thematerial injection flow controller 2050, relative to the materialinjection flow communicator 2048, from the closed position to the openposition with a shifting tool;

while the material injection flow communicator 2048 is disposed in theopen condition, injecting stimulation material, including proppant, fromthe surface 4 and into the subterranean formation 100, via theproduction string 202, the material injection flow communicator 2048,the wellbore space, and the one or more perforations 110 (see FIG. 7),with effect that hydraulic fracturing of a hydrocarbonmaterial-containing reservoir within the subterranean formation 100;

continuing to inject the stimulation material with effect that a screenout is obtained, with effect that the frac pack 212 is obtained withinthe wellbore space section, between the one or more perforations and thematerial production flow communicator (see FIG. 7);

In some embodiments, for example, after the frac pack has been obtained,the stimulation material that has accumulated within the productionstring 202 is cleaned out, such as, for example, by circulating fluidwithin the wellbore between the surface and the flow communicationstation (see FIG. 8).

In some embodiments, for example, a sealed interface 210 is disposedwithin the production string 202, downhole relative to the materialinjection flow communicator 2048. In some embodiments, for example, thesealed interface 210 is provided for preventing, or substantiallypreventing, bypassing of the material injection flow communicator 2048,by stimulation material injected from the surface 4.

In some embodiments, for example, the sealed interface 210 is disposeduphole relative to the material production flow communicator 15. In thisrespect, in some of these embodiments, for example, prior to theproducing (see below), the sealed interface 210 is defeated.

In some embodiments, for example, the sealed interface 210 isestablished, at least in part, with a packer, such as, for example, apacker that is deployed with a bottomhole assembly.

In some embodiments, for example, for each one of the flow communicationstations 200A-E, independently, the injection of the stimulationmaterial is effected while the material production flow communicator 15is disposed in the closed condition.

In some embodiments, for example, after the frac pack has been obtained,and prior to forming a frac pack for the next uphole one of the flowcommunication stations 200A-E, the material injection flow communicator2048 is closed by displacement of the material injection flow controller2050 relative to the flow communicator 2048 with effect that the flowcommunicator 2048 becomes occluded by the flow controller 2050. In someembodiments, for example, such closing of the flow communicator 2048enables the cleaning out of the injected stimulation material, asabove-described.

After the frac pack 212 has been obtained for each one of the flowcommunication stations 200A-E, as above-described, for each one of theflow communication stations 200A-E, independently, and in succession,and while: (i) the material injection flow communicator 2048 is disposedin a closed condition, and (ii) the sealed interface 210 has beenremoved/defeated, the flow control member 14 is displaced for effectingopening of the material production flow communicator 15, to therebyeffect production, via the production string 202, of hydrocarbonmaterial from the subterranean formation 100 (see FIG. 9). In such case,the hydrocarbon material, prior to entering the production string 202,is conducted through the obtained frac pack, thereby effecting removalof some solid particulate matter from the hydrocarbon material beforeits entry into the production string 202.

Referring to FIGS. 10 to 13, in another aspect, another hydrocarbonmaterial production process is provided for implementation with thesystem 100. In this respect, the process includes:

opening the material injection flow communicator 2048 by displacing thematerial injection flow controller 2050 relative to the materialinjection flow communicator 2048;

while the material injection flow communicator 2048 is disposed in theopen condition, injecting stimulation material 300, including proppantentrained within a fluid, from the surface and into the subterraneanformation 100, via the wellbore string 202, the material injection flowcommunicator 2048, and the wellbore space, such that hydraulicfracturing of a hydrocarbon material-containing reservoir of thesubterranean formation 100 is effected (see FIG. 11);

suspending the injection of the stimulation material;

after the suspending of the injection of the stimulation material,partially opening the material production flow communicator 15 bydisplacing the material production flow controller 14 relative to thematerial production flow communicator 15, such that:

-   -   (i) an uphole-disposed portion 15A of the material production        flow communicator is occluded by the material production flow        controller 14; and    -   (ii) flow communication is effected between the subterranean        formation 100 and the wellbore string 202 via a        downhole-disposed portion 15B of the material production flow        communicator 15, such that reservoir material is conducted from        the subterranean formation 100 and into the wellbore string 202        via the downhole-disposed portion 15B of the material production        flow communicator 15 in response to a pressure differential        between the subterranean formation 100 and the wellbore string        202, and such that solid particulate material, entrained within        the conducted reservoir material, separates from the conducted        reservoir material and accumulates within the wellbore space        200, that is disposed between the subterranean formation and the        material production flow communicator, and at least contributes        to formation of a solid particulate material-containing        filtering medium 120 (see FIG. 12);    -   wherein the downhole-disposed portion 15B of the material        production flow communicator 15 is disposed downhole relative to        the uphole-disposed portion 15A of the material production flow        communicator 15;    -   and

after the formation of a solid particulate material-containing filteringmedium 120, increasing the percentage opening of the material productionflow communicator 15 by displacing the material production flowcontroller 14 relative to the material production flow communicator 15such that a production mode material production flow communicator 15C isestablished, with effect that reservoir material is conducted from thesubterranean formation to the wellbore string 202 via the solidparticulate material-containing filtering medium 120 and the productionmode material production flow communicator 15C (see FIG. 13).

The reservoir material 400, including hydrocarbon material, that isreceived within the wellbore string 202 is produced to the surface.

In some embodiments, for example, the partial opening of the flowcommunicator 15 is such that the fluid velocity and pressuredifferential between the reservoir and the wellbore string 202 willtransport material from the reservoir to the filter through naturalflowback. In some embodiments, for example, the flowback velocity iscontrolled through open flow area of the material production flowcommunicator 15 so as to not exceed the erosional fluid velocity limitson the flow communicator 15 while exceeding the transport velocityrequired to deposit materials around the material production flowcommunicator 15. Both cases are governed by the magnitude of reservoirpressure present.

In some embodiments, for example, the solid particulatematerial-containing filtering medium 120 includes solid particulatematerial that has accumulated during the injection of stimulationmaterial.

In some embodiments, for example, the partial opening of the materialproduction flow communicator 15 is with effect that the uphole-disposedportion 15A, of the material production flow communicator 15 that isbeing occluded by the flow controller 14, defines at least 50% of thetotal cross-sectional flow area of the material production flowcommunicator 15, such as, for example, at least 75% of the totalcross-sectional flow area of the material production flow communicator15. In some embodiments, for example, the increasing of the percentageopening of the material production flow communicator 15 is with effectthat the material production flow communicator 15 is disposed in thenon-occluded condition.

In some embodiments, for example, the injection of the stimulationmaterial is effected while the material production flow communicator 15is disposed in the closed condition. In some embodiments, for example,the injection of the stimulation material is effected while a sealedinterface 204 is disposed within the wellbore string 202, downholerelative to the material injection flow communicator 2048.

In some embodiments, for example, where there is a sealed interface 204disposed uphole relative to the material production flow communicator15, after the formation of a solid particulate material-containingfiltering medium 120, and prior to the increasing of the percentageopening of the material production flow communicator 15, the sealedinterface is defeated 204 (for example, a packer is unset).

In some embodiments, for example, prior to the partial opening of thematerial production flow communicator 15, the material injection flowcommunicator 2048 is closed by displacing the flow controller 2050relative to the material injection flow communicator and therebyoccluding the material injection flow communicator 2048.

In some embodiments, for example, displacement of one, or both, of theflow control members 250, 14, in the downhole direction, is effectiblewith a shifting tool, by actuating a bottomhole assembly including ashifting tool and a suitable sealing member (e.g. packer), such that theshifting tool becomes disposed in gripping engagement with the secondflow control member 216 and a suitable sealed interface is established,and applying a fluid pressure differential across the sealed interfacewith effect that the resulting force, being applied in a downholedirection, is translated by the shifting tool to the flow control member216. In those embodiments where the flow control member is beingmaintained in the closed position, by one or more frangible interlockingmembers, in some of these embodiments, for example, the translated forceis sufficient to effect fracturing of the frangible interlockingmembers, and thereby effect release of the flow control member from thehousing such that the flow control member is displaceable relative tothe flow communicator, such as by continued application of thetranslated force. In those embodiments where the flow control member isreleasably retained relative to the housing (such as, for example, inthe closed position) by a collet retainer, the translated force issufficient to effect displacement of the collet retainer such that theflow control member becomes released relative to the housing.

In some embodiments, for example, displacement of one, or both, of theflow control members 250, 14, in the uphole direction, is effectiblewith a shifting tool, by actuating a bottomhole assembly including ashifting tool, such that the shifting tool becomes disposed in grippingengagement with the second flow control member 216 is established, andapplying a tensile force (a force applied in the uphole direction) to aworkstring, with effect that the applied tensile force (e.g. pulling upforce) is translated by the shifting tool to the flow control member216. In those embodiments where the flow control member is releasablyretained relative to the housing (such as, for example, in the openposition) by a collet retainer, the translated force is sufficient toeffect displacement of the collet retainer such that the flow controlmember becomes released relative to the housing.

In some embodiments, for example, the above-described displacements areeffected by the same shifting tool. In some embodiments, for example, anexemplary shifting tool, for effecting the above-describeddisplacements, is the SHIFT FRAC CLOSE™ tool available from NCSMultistage Inc. In some embodiments, for example, the bottomholeassembly 208 is any one of the embodiments of a bottomhole assemblydescribed in U.S. Patent Publication No. 2016/0251939 A1.

In the above description, for purposes of explanation, numerous detailsare set forth in order to provide a thorough understanding of thepresent disclosure. However, it will be apparent to one skilled in theart that these specific details are not required in order to practicethe present disclosure. Although certain dimensions and materials aredescribed for implementing the disclosed example embodiments, othersuitable dimensions and/or materials may be used within the scope ofthis disclosure. All such modifications and variations, including allsuitable current and future changes in technology, are believed to bewithin the sphere and scope of the present disclosure. All referencesmentioned are hereby incorporated by reference in their entirety.

1. A hydrocarbon production process, implemented via a system includinga wellbore string disposed within a wellbore extending into asubterranean formation, wherein the wellbore string includes a flowcommunication station including a material injection station and amaterial production station, wherein the material production station isdisposed downhole relative to the material injection station, whereinthe material injection station includes a material injection flowcontrol member for opening and closing a material injection flowcommunicator that is disposed in flow communication with thesubterranean formation via a wellbore space, and the material productionstation includes a material production flow control member for openingand closing a material production flow communicator that is disposed inflow communication with the subterranean formation via a wellbore space,wherein the material production flow communicator includes a filtermedium for preventing oversize particulate material from entering thewellbore string, comprising: opening the material injection flowcommunicator by displacing the material injection flow control member,relative to the material injection flow communicator, with a shiftingtool; while the material injection flow communicator is disposed in theopen condition, injecting stimulation material, including proppant thatis entrained within a fluid, from the surface and into the subterraneanformation, via the wellbore string, the material injection flowcommunicator, and the wellbore space, such that hydraulic fracturing ofa hydrocarbon material-containing reservoir of the subterraneanformation is effected; continuing to inject the stimulation materialwith effect that a frac pack is obtained within the wellbore space,between the subterranean formation and the material production flowcommunicator; and after the frac pack has been obtained: suspending theinjection of the stimulation material; after the suspending of theinjection of the stimulation material, opening the material productionflow communicator by displacing the material production flow controlmember, relative to the material production flow communicator, with ashifting tool; and after the opening of the material production flowcommunicator, producing hydrocarbon material from the subterraneanformation via the frac pack, the material production station and thewellbore string.
 2. The process as claimed in claim 1; wherein theinjection of the stimulation material is effected while the materialproduction flow communicator is disposed in the closed condition.
 3. Theprocess as claimed in claim 1 or 2; wherein the injection of thestimulation material is effected while a sealed interface is disposedwithin the wellbore string, downhole relative to the material injectionflow communicator.
 4. The process as claimed in claim in any one ofclaims 1 to 3; wherein the sealed interface is disposed uphole relativeto the material production flow communicator; and further comprising:after the frac pack has been obtained, and prior to the opening of thematerial production flow communicator, defeating the sealed interface.5. The process as claimed in any one of claims 1 to 4, furthercomprising: prior to the opening of the material production flowcommunicator, closing the material injection flow communicator.
 6. Theprocess as claimed in any one of claims 1 to 5; wherein both of: (i) thedisplacing of the material injection flow control member, relative tothe material injection flow communicator, from the closed position tothe open position; and (ii) the displacing of the material productionflow control member, relative to the material production flowcommunicator, from the closed position to the open position; is effectedby the same shifting tool.
 7. The process as claimed in any one ofclaims 1 to 6; wherein: the material injection flow control memberincludes a sleeve; and the material production flow control memberincludes a sleeve.
 8. The process as claimed in any one of claims 1 to7; wherein: prior to the opening of the material production flowcommunicator, the material production flow control member is releasablyretained, relative to the wellbore string, in a retained position by afragible interlocking member; and further comprising: applying a force,in a downhole direction, wherein, in response to the application of thethe downhole-directed force, fracturing of the frangible interlockingmember is effected such that release of the material production flowcontrol member, from the retention relative to the wellbore string, iseffected.
 9. The process as claimed in claim 8; wherein: thedownhole-directed force is applied to the material production flowcontrol member; and after the release of the material production flowcontrol member, from the retention relative to the wellbore string, andin response to the application of the downhole-directed force,displacement of the material production flow control member, relative tothe material production flow communicator, is effected in a downholedirection; such that, in response to the application of thedownhole-directed force: (i) the release of the material production flowcontrol member, from the retention relative to the wellbore string, iseffected; and (ii) after the release of the material production flowcontrol member from the retention relative to the wellbore string,displacement of the material production flow control member, relative tothe material production flow communicator, is effected in a downholedirection; and such that the opening of the material production flowcontrol member includes the displacement of the material production flowcontrol member, relative to the material production flow communicator,in a downhole direction.
 10. The process as claimed 9; wherein thedistance by which the material production flow control member isdisplaced, relative to the material production flow communicator, fromthe retained position, in response to the application of thedownhole-directed force, is less than six (6) inches.
 11. The process asclaimed 9; wherein the distance by which the material production flowcontrol member is displaced, relative to the material production flowcommunicator, from the retained position, in response to the applicationof the downhole-directed force, is less than three (3) inches.
 12. Theprocess as claimed 9; wherein the distance by which the materialproduction flow control member is displaced, relative to the materialproduction flow communicator, from the retained position, in response tothe application of the downhole-directed force, is less than two (2)inches.
 13. The process as claimed in any one of claims 10 to 12;wherein: the system further includes a hard stop; the materialproduction flow control member and the hard stop are co-operativelyconfigured such that: while the material production flow control memberis disposed in the retained position, the hard stop is disposed downholerelative to the flow control member by a distance of less than sixinches; and after the material production flow control member has beenreleased from the retention relative to the wellbore string and is beingdisplaced in a downhole direction by the downhole-directed force, thehard stop is disposed for becoming disposed in abutting engagement withthe material production flow control member for preventing, orsubstantially preventing, displacement of the flow control member,relative to the material production flow communicator, in the downholedirection.
 14. The process as claimed in claim 13; wherein thedisplacement of the material production flow control member, relative tothe material production flow communicator, in a downhole direction, thatis effected in response to the application of the downhole-directedforce, is with effect that the material production flow control memberbecomes disposed in abutting engagement with the hard stop, such thatdisplacement of the material production flow control member, relative tothe material production flow communicator, in the downhole direction isprevented, or substantially prevented, by the hard stop.
 15. The processas claimed in any one of claims 9 to 14, further comprising: after theapplication of the downhole-directed force that has displaced thematerial material production flow control member, relative to thematerial production flow communicator, in a downhole direction,displacing the material production flow control member, relative to thematerial production flow communicator, in an uphole direction, witheffect that the material production flow communicator become disposed ina non-occluded condition; such that the opening of the materialproduction flow control member includes the displacing of the materialproduction flow control member, relative to the material production flowcommunicator, in an uphole direction.
 16. The process as claimed inclaim 15; wherein, in the non-occluded condition, there is an absence,or substantial absence, of occlusion of any portion of the materialproduction flow communicator by the material production flow controlmember.
 17. The process as claimed in claim 16; wherein a dimension ofthe material production flow communicator, measured along an axis thatis parallel, or substantially parallel, to the central longitudinal axisof the wellbore string, is at least one (1) foot.
 18. The process asclaimed in claim 16; wherein a dimension of the material production flowcommunicator, measured along an axis that is parallel, or substantiallyparallel, to the central longitudinal axis of the wellbore string, is atleast three (3) feet.
 19. The process as claimed in claim 16; wherein adimension of the material production flow communicator, measured alongan axis that is parallel, or substantially parallel, to the centrallongitudinal axis of the wellbore string, is at least five (5) feet. 20.The process as claimed in any one of claims 15 to 19; wherein thematerial production flow communicator and the material production flowcontrol member are co-operatively configured such that the minimumdistance, by which the material production flow control member isdisplaced, relative to the material production flow communicator, in theuphole direction and along an axis that is parallel, or substantiallyparallel, to the central longitudinal axis of the wellbore string, fromthe retained position, for effecting disposition of the materialproduction flow communicator in the non-occluded condition, is at leastone (1) foot.
 21. The process as claimed in claim 20; wherein theminimum distance is at least three (3) feet.
 22. The process as claimedin claim 20; wherein the minimum distance is at least five (5) feet. 23.The process as claimed in claim 14, further comprising: after theapplication of the downhole-directed force that has displaced thematerial material production flow control member, relative to thematerial production flow communicator, in a downhole direction,displacing the material production flow control member, relative to thematerial production flow communicator, in an uphole direction, witheffect that the material production flow communicator become disposed ina non-occluded condition; such that the opening of the materialproduction flow control member includes the displacing of the materialproduction flow control member, relative to the material production flowcommunicator, in an uphole direction; wherein: in the non-occludedcondition, there is an absence, or substantial absence, of occlusion ofany portion of the material production flow communicator by the materialproduction flow control member; and the material production flowcommunicator and the material production flow control member areco-operatively configured such that the minimum distance, by which thematerial production flow control member is displaced, relative to thematerial production flow communicator, in the uphole direction and alongan axis that is parallel, or substantially parallel, to the centrallongitudinal axis of the wellbore string, from, for from the position atwhich the flow control member is disposed while in abutting engagementwith the hard stop, is at least 14 inches.
 24. The process as claimed inclaim 23; wherein the minimum distance is at least 38 inches.
 25. Theprocess as claimed in claim 23; wherein the minimum distance is at least62 inches.
 26. The process as claimed in any one of claims 23 to 26;wherein a dimension of the material production flow communicator,measured along an axis that is parallel, or substantially parallel, tothe central longitudinal axis of the wellbore string, is at least one(1) foot.
 27. The process as claimed in any one of claims 23 to 26;wherein a dimension of the material production flow communicator,measured along an axis that is parallel, or substantially parallel, tothe central longitudinal axis of the wellbore string, is at least three(3) feet.
 28. The process as claimed in any one of claims 23 to 26;wherein a dimension of the material production flow communicator,measured along an axis that is parallel, or substantially parallel, tothe central longitudinal axis of the wellbore string, is at least five(5) feet.
 29. The process as claimed in any one of claims 15 to 28;wherein the displacement of the material production flow control member,relative to the material production flow communicator, in the upholedirection is with effect that the entirety, or the substantial entirety,of the material production flow communicator is non-occluded by thematerial production flow control member.
 30. The process as claimed inany one of claims 8 to 29; wherein the retained position corresponds todisposition of the material production flow control member in the closedposition.
 31. A hydrocarbon production process, implemented via a systemincluding a wellbore string disposed within a wellbore extending into asubterranean formation, wherein the wellbore string includes a materialinjection station and a material production station, wherein thematerial production station is disposed downhole relative to thematerial injection station, wherein the material injection stationincludes a material injection flow controller for modulating a flowcommunication condition of a material injection flow communicator thatis disposed in flow communication with the subterranean formation via awellbore space, and the material production station includes a materialproduction flow controller for modulating a flow communication conditionof a material production flow communicator that is disposed in flowcommunication with the subterranean formation via a wellbore space,wherein the material production flow communicator includes a filtermedium for preventing oversize particulate material from entering thewellbore string, comprising: opening the material injection flowcommunicator by displacing the material injection flow controllerrelative to the material injection flow communicator; while the materialinjection flow communicator is disposed in the open condition, injectingstimulation material, including proppant entrained within a fluid, fromthe surface and into the subterranean formation, via the wellborestring, the material injection flow communicator, and the wellborespace, such that hydraulic fracturing of a hydrocarbonmaterial-containing reservoir of the subterranean formation is effected;suspending the injection of the stimulation material; after thesuspending of the injection of the stimulation material, partiallyopening the material production flow communicator by displacing thematerial production flow controller relative to the material productionflow communicator, such that: (i) an uphole-disposed portion of thematerial production flow communicator is occluded by the materialproduction flow controller; and (ii) flow communication is effectedbetween the subterranean formation and the wellbore string via adownhole-disposed portion of the material production flow communicator,such that reservoir material is conducted from the subterraneanformation and into the wellbore string via the downhole-disposed portionof the material production flow communicator in response to a pressuredifferential between the subterranean formation and the wellbore string,and such that solid particulate material, entrained within the conductedreservoir material, separates from the conducted reservoir material andaccumulates within the wellbore space, that is disposed between thesubterranean formation and the material production flow communicator,and at least contributes to formation of a solid particulatematerial-containing filtering medium; wherein the downhole-disposedportion of the material production flow communicator is disposeddownhole relative to the uphole-disposed portion of the materialproduction flow communicator; and after the formation of a solidparticulate material-containing filtering medium, increasing thepercentage opening of the material production flow communicator bydisplacing the material production flow controller relative to thematerial production flow communicator such that a production modematerial production flow communicator is established, with effect thatreservoir material is conducted from the subterranean formation and intothe wellbore string via the solid particulate material-containingfiltering medium and the production mode material production flowcommunicator.
 32. The process as claimed in claim 31; wherein thepartial opening of the material production flow communicator is witheffect that the uphole-disposed portion, of the material production flowcommunicator that is being occluded by the flow controller, defines atleast 50% of the total cross-sectional flow area of the materialproduction flow communicator.
 33. The process as claimed in claim 31;wherein the partial opening of the material production flow communicatoris with effect that the uphole-disposed portion, of the materialproduction flow communicator that is being occluded by the flowcontroller, defines at least 75% of the total cross-sectional flow areaof the material production flow communicator.
 34. The process as claimedin any one of claims 31 to 34; wherein the increasing of the percentageopening of the material production flow communicator is with effect thatthe material production flow communicator is disposed in thenon-occluded condition.
 35. The process as claimed in any one of claims31 to 34; wherein solid particulate material-containing filtering mediumincludes solid particulate material that has accumulated during theinjection of stimulation material.
 36. The process as claimed in any oneof claims 31 to 35; wherein the injection of the stimulation material iseffected while the material production flow communicator is disposed inthe closed condition.
 37. The process as claimed in any one of claims 31to 36; wherein the injection of the stimulation material is effectedwhile a sealed interface is disposed within the wellbore string,downhole relative to the material injection flow communicator.
 38. Theprocess as claimed in claim 37; wherein the sealed interface is disposeduphole relative to the material production flow communicator; andfurther comprising: after the formation of a solid particulatematerial-containing filtering medium, and prior to the increasing of thepercentage opening of the material production flow communicator,defeating the sealed interface.
 39. The process as claimed in any one ofclaims 31 to 38, further comprising: prior to the partial opening of thematerial production flow communicator, closing the material injectionflow communicator.
 40. The process as claimed in any one of claims 31 to39; wherein: the displacing of the material injection flow controller,relative to the material injection flow communicator, is effected by ashifting tool; and the displacing of the material production flowcontroller, relative to the material injection flow communicator, iseffected by a shifting tool.
 41. The process as claimed in any one ofclaims 31 to 39; wherein both of: (i) the displacing of the materialinjection flow control member relative to the material injection flowcommunicator; and (ii) the displacing of the material production flowcontrol member relative to the material production flow communicator; iseffected by the same shifting tool.
 42. The process as claimed in anyone of claims 31 to 40; wherein: the material injection flow controlmember includes a sleeve; and the material production flow controlmember includes a sleeve.